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CALIFORNIA PUBLIC UTILITIES COMMISSION
CONSUMER PROTECTION & SAFETY DIVISION UTILITIES SAFETY & RELIABILITY BRANCH
ELECTRIC, NATURAL GAS & PROPANE SAFETY REPORT
2007
SEPTEMBER 2008
Headquarters Sacramento Office Los Angeles Office 505 Van Ness Avenue 515 “L” Street, Suite 1119 320 West 4th Street, Suite 500 San Francisco, CA 94102 Sacramento, CA 95814 Los Angeles, CA 90013
i
Page No. Executive Summary .......................................................................................... iii INTRODUCTION.............................................................................................. 1 SECTION I: GAS SAFETY COMPLIANCE INSPECTIONS, REPORTS,
AND PROGRAMS................................................................... 2 1. General Order 112-E..................................................................................2 2. Description of a Typical GO 112-E Inspection .........................................3 3. Mobile Home Park (MHP) Program..........................................................4 4. Propane Safety Program (PSP) ..................................................................5 5. Gas Incident Reports..................................................................................7 6. Safety Related Condition Reports..............................................................8 7. Drug and Alcohol Testing Program...........................................................9 8. Underground Service Alert (USA) ............................................................9 9. Pipeline Replacement Program (PRP) .....................................................10 10. Operator Qualification and Pipeline Integrity Management..................12 11. Pipeline Inspection, Protection, Enforcement and Safety Act ...............13 12. Meter Protection Program......................................................................13 13. Granting Of Waivers..............................................................................14 14. Above Ground Pipe Inspections ............................................................14 15. Other Programs ......................................................................................15 16. Other Duties Required by the Pipeline Safety Act ................................16 17. DOT Annual Audit ................................................................................17
SECTION II: ELECTRIC SAFETY INSPECTIONS, REPORTS, AND PROGRAMS .......................................................................... 18
1. Electric Safety and Inspection Program...................................................18 2. Incident Reporting and Investigation.......................................................19 3. Heat Storm ...............................................................................................20 4. Substation Inspection Program ................................................................20 5. GO 95 Antenna Rule................................................................................21 6. Fire Storm ................................................................................................21 7. Communication Infrastructure Providers (CIP).......................................23
SECTION III: UTILITY COMPANIES ....................................................... 24 1. Major Natural Gas and Electric Utilities .................................................24 2. Other Natural Gas Companies ..................................................................25 3. Other Electric Service Companies ............................................................26
SECTION IV: GAS STATISTICS................................................................ 28 1. Size and Character of the California Gas System....................................28 2. USRB Inspection Data.............................................................................32 3. Gas Incidents............................................................................................34
SECTION V: ELECTRIC STATISTICS................................................... 36 1. Major Electric Utility Data (Overhead) ...................................................37 2. Electric Utility Data (Underground) ........................................................38 3. Electric Utility Customer Data.................................................................38
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4. USRB Electric Inspection Data ...............................................................40 5. Electric Incidents .....................................................................................40
a. Overhead Equipment..................................................................41 b. Underground Equipment...........................................................43
SECTION VI: PUBLIC COMPLAINTS AND INQUIRIES ..................... 44
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Executive Summary This report presents an account of various activities carried out under the California Public
Utilities Commission’s (CPUC) natural gas, electrical, mobile home park, and propane safety
programs for calendar year 2007. The CPUC has been entrusted with safety jurisdiction for
these facilities in the state by legislative mandate. It is responsible for enforcing safety
regulations, inspecting all work affected by the statutes, and making necessary additions and
changes to regulations for promoting the safety of the general public and the utility employees
that work on the various systems.
General Regulations for the natural gas and propane safety programs are stated in General Order (GO)
112-E. GO 112-E adopts Title 49 of the Code of Federal Regulations (49 CFR), Parts 190, 191,
192, 193, 199 and Part 40 that pertain to natural gas and/or propane safety. GO 112-E also
includes regulations, which are more stringent than the federal regulations. Other pertinent
legislation is contained in the Public Utilities (PU) Code. The CPUC has also been entrusted
with safety jurisdiction over all electric supply and communication overhead and underground
facilities in the state of California. The electric safety program consists of the administration of
GOs 95, 128, 165 and PU Code, Sections 315, 768, 8026 through 8038, and 8051 through 8057.
The State of California has the nation’s largest electric supply and communication systems.
The CPUC’s Utilities Safety and Reliability Branch (USRB) oversees the gas and electric safety
programs and maintains an adequate level of inspections and surveillance to ensure that these
public utility systems are designed, constructed, operated, and maintained in accordance with the
regulations for safety of the general public and utility employees. USRB also conducts accident
investigations, compliance inspections, reviews of utilities’ reports and records, construction
inspections, and special studies, and takes action in response to complaints and inquiries from the
general public on issues regarding gas pipeline and electrical safety. USRB is part of the
CPUC’s Consumer Protection and Safety Division (CPSD).
iv
Gas Inspection Results The California gas system (natural gas and propane) serves approximately 11 million customers
with 100,000 miles of gas mains. Table I and Figure I below illustrate the miles and types of
pipelines that make up the natural gas distribution systems in California as reported by pipeline
operators to the Department of Transportation (DOT).
Steel Pipe Unprotected Protected Company
Bare Steel Coated Steel
Bare Steel
Coated Steel
Plastic Cast Iron Total
PG&E 213 0 0 20,880 20,528 182 41,803 SCG 3,381 5,600 149 16,713 21,723 0 47,566 SDG&E 0 0 0 3,731 4,607 0 8,338 SWG 0 1 0 613 2,419 0 3,033 SCE 0 0 0 9 0 0 9 Total 3,594 5,601 149 41,946 49,277 182 100,749
Table I. Miles of Distribution Pipeline by Utility
Distribution Pipeline In Use 2007
Cast Iron0.2% Unprotected Bare
Steel3.6%
Unprotected Coated Steel5.6%Protected Bare Steel
0.15%
Plastic48.9%
Protected Coated Steel
41.6%
Figure I. Distribution Pipeline by Type
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Section IV contains additional information concerning the characteristics of the California gas
system.
USRB is divided into two sections, North and South. Each is assigned specific counties in which
to conduct GO 112-E inspections. Table II below presents a summary of gas inspections
performed by USRB in 2007. Inspections of major utilities are generally conducted over a three
or four day period to determine compliance with CPUC gas regulations per GO 112-E and the
federal gas regulations. Mobile home Park and Propane inspections are conducted within one
day. The methodologies USRB uses to inspect the gas systems of gas utilities, mobile home
parks (MHP), and propane entities are described in Section I.
Major Utilities MHP Propane Total
Inspections 31 716 204 951
Infractions 59 2,967 680 3,706
Table II. Summary of Gas Safety Inspections
Major gas utilities are inspected every two or three years, or more often if conditions are
discovered that are unsafe or not in compliance with GO 112-E. MHP gas systems are inspected
every five years. Propane systems are inspected every two, three, or five years depending upon
the size and history of the propane system.
Gas Incidents USRB receives and investigates reportable natural gas incidents from regulated utility
companies. USRB also investigates gas incidents reported by MHP and propane system
operators. GO 112-E defines reportable incidents as those that involve a release of gas and: (a)
result in a fatality or personal injury requiring in-patient hospitalization, (b) cause over $50,000
in damage including the loss of gas, or (c) become the subject of significant public attention or
media coverage. Table III and Figure II provide a summary of reported gas incidents. In 2007,
the single most common cause of the reportable gas incidents was excavations. USRB is active
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in the California Regional Common Ground Alliance which proactively seeks to reduce incidents
caused by excavation.
Cause Total Corrosion 1 Excavation 49 Vehicle 13 Fire 11 Other 12 Unknown 3 Total 89
Table III. GO 112-E Reportable Gas Incidents by Cause in 2007
Reportable Gas Incidents By Cause 2007
Unknow n3.4%
Other13.5%
Corrosion1.1%
Excavation55.1%
Vehicle14.6%
Fire12.4%
Figure II. GO 112-E Reportable Gas Incidents by Cause
Electric Inspection Results
USRB enforces the provisions of GOs 95, 128, and 165. USRB conducts periodic inspections of
both overhead and underground electric supply, and communication lines throughout the state.
The methodologies USRB uses to inspect electric and communication facilities are described in
Section II. Data for overhead electric facilities are summarized in Table IV and Figure III below.
Table V provides data for underground electric facilities.
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Utility Company Overhead
Transmission Lines (miles)
Overhead Distribution Lines
(miles) Total Overhead
Lines (miles) Number of
Poles
PG&E 18,515 113,525 132,040 2,305,000 SCE 11,675 59,870 71,545 1,486,399 SDG&E 1,741 6,713 8,454 216,881 PacificCorp. 741 2,293 3,034 67,303 Sierra Pacific Power 1,041 2,812 3,853 22,653 Total 33,713 185,213 218,926 4,098,236
Table IV. Summary of Overhead Electric Facilities in 2007
2007 Overhead Transmission And Distribution
18,515 11,675 1,741 7411,041
113,525
59,870
6,713 2,8122,293
0
20,000
40,000
60,000
80,000
100,000
120,000
PG&E SCE SDG&E PacificCorp. Sierra PacificPower
Utility
Mile
s
Transmission Distribution
Figure III. Electric Transmission and Distribution Lines by Utility in 2007
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Utility Company Underground Transmission Lines (miles)
Underground Distribution Lines (miles)
Total Underground Lines (miles)
Surface Mounted
Structures Underground
Structures
PG&E 165 27,159 27,324 135,928 203,893 SCE 292 39,843 40,135 123,864 334,442 SDG&E 91 9,822 9,913 109,928 43,936 PacificCorp. 0 581 581 5,892 236 Sierra Pacific Power 0 779 779 2,309 1,762 Total 548 78,184 78,732 377,921 584,269
Table V. Summary of Underground Electric Facilities in 2007
USRB engineers conduct combined inspections of overhead and underground electric lines for
compliance with GO 95, 128, and 165. During the inspection, USRB engineers survey electric
facilities and perform a document review of pertinent records over a three or four day period.
The record review is validated by spot checks in the field. Each violation discovered is
documented and discussed with the appropriate utility personnel. This procedure expedites the
violation correction process. Table VI summarizes the inspections and infractions cited by
USRB inspectors in 2007.
Infractions Utility Inspections
GO 165 GO 95 (overhead)
GO 128 (underground)
Pacific Gas and Electric 7 10 25 7 Southern California Edison 6 1 239 113 San Diego Gas and Electric 2 4 10 2 Sierra Pacific Power 0 0 0 0 Municipalities / Others 13 6 195 85 Total 28 21 469 207
Table VI. Summary of Inspections and Infractions in 2007
Electric Incidents USRB staff receives and investigates reportable electric incidents from regulated utility
companies. Reportable incidents for 2007 are those which (a) result in fatality or personal injury
rising to the level of in-patient hospitalization, (b) result in property damage of $20,000 or more,
or (c) are the subject of significant public attention or media coverage. Pacific Gas and Electric
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(PG&E), Southern California Edison (SCE), and San Diego Gas and Electric (SDG&E)
successfully petitioned the CPUC to remove the requirement for reporting when the incident
only involved trees or vegetation.
There were 135 total incidents reported in 2007. Of these, 96 were related to overhead
equipment, and 39 involved underground equipment. Section V contains a detailed breakdown
of incidents by type.
General Public Complaints and Inquiries USRB also responds to complaints and inquiries from the general public in all of the areas under
USRB’s jurisdiction. There were 53 customer complaints and inquiries in 2007. Section VI
contains a summary by type of complaint.
Special Projects In addition to the regular activities described above, USRB was active in the following special
projects in 2007:
• Communications Infrastructure Providers inspection program – developed an inspection
program targeted at communications overhead and underground infrastructure.
• Propane citation authority – developed a process for Commission adoption empowering
USRB to directly cite propane operators without requiring additional Commission action
for each citation.
• GO 95 update – finalized inclusion of pole mounted antennas to include antennas owned
by municipalities and Wi-Fi antennas.
• 2006 Summer Heat Storm investigation – continued study of electric distribution
equipment failures during the heat storm.
• Fire Storm Investigation – continued investigation to determine causes of fires that
occurred in Southern California in October 2007.
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INTRODUCTION
PURPOSE OF REPORT AND ORGANIZATION
This Annual Report provides general information about the Utilities Safety and
Reliability Branch (USRB) activities, and summarizes the progress of its safety programs
during the 2007 calendar year.
The California Public Utilities Commission (CPUC) monitors the pipeline safety of
investor-owned gas utilities, mobile home parks (MHP) and certain propane systems
under General Order (GO) 112-E. USRB is charged with enforcing GO 112-E, which
adopts Title 49 of the Code of Federal Regulations (49 CFR), Sections 190, 191, 192,
193, and 199. The CPUC also administers GOs 95, 128, and 165 which contain rules for
electric supply and communication installation, safety, and maintenance.
The mission of USRB is to regulate pipeline and electrical safety of utilities under CPUC
jurisdiction and assure an acceptable level of operational safety and reliability for the
protection of the public and the utilities’ employees.
Section I of this report provides a discussion of USRB’s gas safety compliance and
inspection programs. Section II provides a description of USRB’s electric supply and
communication safety inspections, reports and programs. Section III lists the utilities
operating in California by type. Section IV provides statistical data regarding gas
facilities, USRB inspection results, and gas incidents reported and investigated by USRB.
Section V provides statistical data regarding electric systems, inspection results, and
electric incidents reported and investigated. Section VI summarizes general public
complaints and inquiries received and addressed by USRB.
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SECTION I: GAS SAFETY COMPLIANCE INSPECTIONS, REPORTS, AND PROGRAMS
1. General Order 112-E
In 1995, the CPUC adopted the sections of 49 CFR pertinent to gas safety in GO 112-E.
Subsequent changes to the Federal Pipeline Safety Regulations, 49 CFR, Parts 190, 191,
192, 193, and 199 are automatically updated in GO 112-E with the effective date being
the date of the final order as published in the Federal Register.
The Federal Department of Transportation (DOT) has jurisdiction for enforcing the
regulations in 49 CFR. In November 2004, Congress authorized the partial
reorganization of the DOT. Part of this reorganization created the Pipeline and
Hazardous Materials Safety Administration (PHMSA), which replaced the Research and
Special Programs Administration. The intent of this reorganization was to place a clear
emphasis on the importance of safety in pipeline transportation and hazardous materials
transportation. DOT also oversees the PHMSA Office of Training & Qualifications
(T&Q). Both PHMSA and T&Q play a role in enforcement and education with regard to
federal regulations pertaining to gas pipeline safety.
USRB conducts audits and inspections of gas facilities owned and operated by investor -
owned utilities and master meter Mobile Home Park (MHP) operators for compliance
with GO 112-E. USRB also audits and inspects underground propane gas distribution
systems.
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2. Description of a Typical GO 112-E Inspection
Investor-owned utilities are made up of a number of operational units or divisions, each
of which is normally audited every two or three years. Some districts, such as those of
Southern California Gas Company, are audited annually. When a significant problem is
found, the frequency of inspections is increased depending on the severity of the
problem. Once the problem is remedied, to the satisfaction of USRB, the unit returns to
its normal inspection cycle.
USRB inspectors review records and pertinent documents and conduct field audits to
determine if gas facilities are being properly maintained and operated. As part of the
document review, USRB inspectors determine if the utility possesses a complete and
accurate map of the gas or propane system, an adequate Operation and Maintenance
(O&M) Plan, an Emergency Plan, and an Operator Qualification Program (with
documentation that the plans and programs are being followed). The inspectors review
the utility’s records to verify that both proper maintenance and appropriate surveys, such
as cathodic protection, leak detection, and odorant checks are performed in accordance
with state and federal regulations. While auditing the written records in the office, USRB
inspectors select utility facilities to inspect in the field.
The field inspection focuses on verifying the utility’s records and maps, physically
operating valves, checking regulator set points, randomly testing cathodic protection
areas, and verifying that unsafe conditions noted by USRB in past inspections were
corrected. Inspectors observe the overall condition of the system and how the utility
follows its own written procedures. The field inspections also allow inspectors to
confirm the qualifications of operators’ employees. USRB inspectors will cite the utility
for non-compliances and specify the time in which corrective action must be taken.
USRB inspectors will monitor the utility until the non-compliances are corrected. USRB
inspectors sometimes suggest changes in utility procedures to improve gas pipeline
safety. USRB inspectors also audit records pertaining to the anti-drug and alcohol
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programs performed by the utilities (propane and MHP operators are exempt from this
federal requirement).
3. Mobile Home Park (MHP) Program
Most natural gas customers in California receive gas directly from, and are billed by, the
local gas utility. However, residents of some MHPs do not receive gas directly from the
local utility, but instead receive gas from, and are billed by, their MHP operator. In this
case, the MHP gas system is master-metered. The MHP operator receives natural gas at a
discount since the local utility is not responsible for maintaining and operating MHP gas
systems that are master-metered. The MHP operator, in turn, bills its residents at the
rates that are prescribed in CPUC’s tariffs for the serving utility. The difference between
what the master-meter operator pays for gas from the utility and what the operator may
charge its residents is used primarily to maintain the gas system.
Under 49 CFR, California Public Utilities (PU) Code (4351-4361), and GO 112-E, the
MHP program provides for inspections of MHP master-metered gas systems. USRB
inspectors are responsible for carrying-out this program and have the authority to cite
operators who are not in compliance with the Federal regulations. Regulations for MHP
gas systems have been collected in the "Guidance Manual for Operators of Small Gas
Systems" (http://ops.dot.gov/regs/small_ng/SmallNaturalGas.htm ). Operators are
required to have a map of the MHP gas system with key valve locations, adequate O&M
and Emergency Plans, and an Operator Qualification Program to assure safe operation of
their gas systems. USRB inspectors verify that the MHP operators know the
requirements of the gas safety code and understand the operation and maintenance of
their gas systems. USRB inspectors also perform visual inspections of the MHP gas
systems to determine if unsafe conditions exist.
In addition to inspections, USRB offers training seminars to MHP master-meter operators
to reacquaint seasoned operators and introduce new operators to the requirements for
operating a gas system. USRB is responsible for inspecting over 2,600 master-metered
MHPs in California ranging in size from two customers to over 1,000 customers at least
5
once every five years. Many of the MHPs require special attention to meet the
requirements. This requires USRB to conduct follow-up inspections of certain MHP gas
systems more than once during the five-year period.
USRB logs the results of each inspection into a database. USRB engineers use the
database to follow-up and assure that operators who have been cited take appropriate
action. MHP operators are required to submit an annual report to the CPUC regarding
their gas systems, which is also entered into the database. The database is also used to
identify problem areas, which need to be addressed. The program continues to be
successful. USRB inspectors have discovered and caused MHP operators to correct
potentially dangerous situations, which if not corrected, could have resulted in serious gas
incidents.
In 2007, PHMSA relaxed Public Awareness Program (PAP) requirements for small
operators, i.e., MHP and propane systems. Prior to the new requirement, small operators
were expected to develop and implement public education programs just as large utilities
do. In 2008, USRB expects to educate and assist small operators in developing or
updating their PAP.
4. Propane Safety Program (PSP)
Pursuant to 49 CFR, PU Code (4451-4465), and GO 112-E, the PSP directs operators of
jurisdictional propane distribution systems in California to comply with the Federal
Pipeline Safety Standards to protect the health and safety of the operators, their
employees and the customers they serve. The CPUC oversees the safety of all propane
distribution systems serving 10 or more customers in a residential or commercial district,
two or more customers in a MHP, and any system with two or more customers in a public
place. Under existing PU Code, jurisdictional propane systems serving over 200
customers are subject to an inspection every two years. Propane systems that serve at
least 100, but less than 200 customers, are to be inspected every three years.
Approximately 95% of the propane systems serve less than 100 customers and are to be
audited at least once every five years.
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USRB inspectors work with the propane industry, mainly through the Western Propane
Gas Association to improve the PSP. Many propane system operators are also the
propane suppliers. These operators are usually knowledgeable about their propane
systems, safety requirements, and the federal regulations. Federal regulations that apply
to propane distribution systems are contained in the Guidance Manual for Operators of
Small LP Gas Systems( http://ops.dot.gov/regs/small_lp/SmallLPGas.htm ).
Based on its experience to date with the PSP, USRB is working at solving several
problems. One problem that USRB has experienced since the inception of the PSP is
identifying jurisdictional propane systems. USRB maintains a database of propane
systems similar to the MHP Database, but there is no requirement that operators of new
propane systems report the establishment of these systems to the CPUC. As a result,
when out in the field conducting routine inspections, USRB inspectors are constantly
looking for jurisdictional propane systems that are not included in the database. The PSP
Database must be continuously updated to reflect the addition of new jurisdictional, and
removal of non-jurisdictional, propane entities. USRB also collects information from
propane suppliers, especially concerning new construction.
USRB has occasionally found it difficult to persuade propane operators to correct
common problems discovered during routine inspections. Cathodic protection and record
keeping are prime examples. USRB is trying to educate the small propane system
operators and suppliers to help them better understand the gas safety regulations and what
they need to do in order to achieve compliance at a minimal expense. In 2007, USRB
developed citation procedures similar to those in the MHP program to help USRB
inspectors enforce the PSP. USRB drafted a resolution presented to the CPUC for
approval to cite individual operators without seeking additional CPUC action. USRB will
meet with propane operators and propane service providers to inform them of the
potential consequences for regulatory noncompliance.
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PU Code § 4458 requires jurisdictional propane system operators to pay an annual
user fee to the CPUC. At present, the fee is set at twenty-five cents per unit per
month or $3.00 per unit per year. In accordance with the legislation enacted to
implement the PSP, every operator of a propane system serving ten or more units
in a commercial or residential area or two or more units in a MHP must prepare
and submit to the CPUC a completed Annual Report form and pay the annual user
fee.
Collecting the user fee can be problematic due to the changes in propane system
ownership, operators, propane suppliers or maintenance staff. This is the only program
for which USRB is obligated to invoice and collect a user fee.
5. Gas Incident Reports
USRB monitors and investigates gas incidents, which occur in the service territory of
utilities under CPUC jurisdiction. The purpose is twofold: first, to determine the cause
and whether the utility was negligent or violated GO 112-E; and second, to determine if
measures can be taken to prevent similar incidents. USRB maintains a database of all
reportable gas related incidents. The Incident Database helps USRB to monitor the gas
incidents and track trends. Tracking leak histories and incident occurrences have led to
the “Pipeline Replacement Program”, “Meter Protection Program” and the “Above
Ground Pipeline Inspection Program”. These programs are discussed in more detail in
subsections 9, 12, and 14.
Each utility is required to report any incident which involves a release of gas and (a)
results in death or injury requiring in-patient hospitalization, (b) results in $50,000 or
more of damage to property, including loss of gas, or (c) in the operator’s judgment is
significant, to the CPUC and DOT. These incidents are to be reported to the CPUC
within two hours (during working hours) and four hours (during non-working hours) of
utility personnel arriving on the scene. The CPUC also requires an operator to report an
incident if there is significant media attention. Most incidents are reported because they
involve damage over $50,000. In 2007, there were no fatalities and only eleven injuries
8
related to natural gas incidents. Most injuries were to third parties rather than utility
employees. USRB determined that 70 gas incidents were reportable in 2007.
GO 112-E requires the utility to file a quarterly report listing all reportable and non-
reportable incidents that involve the escape of natural gas. This report includes all
incidents caused by excavation or that involve fire or explosion, regardless of the amount
of property damage. On average, it includes between 400 and 500 gas events each year.
This data is tabulated, analyzed and used to evaluate the need to develop new gas safety
programs or modify existing ones.
USRB staff investigates all reportable incidents, but only conducts full-scale
investigations for those incidents it believes are significant. This may be done by visiting
the site, making written data requests, interviewing the gas operator and witnesses to the
incident or a combination of these activities. Leading causes of gas incidents for 2007
are presented in Table 8, page 35. Homeowners and small contractors digging near gas
pipelines cause many incidents. Most of these incidents are not immediately reportable
because they do not meet the criteria established by the CPUC or DOT but should be
included in the quarterly report.
6. Safety Related Condition Reports
Safety Related Condition Reports are required by the DOT to monitor situations that
could affect public safety if not repaired in a timely manner. These reports are generally
required in the event of a natural disaster, or physical damage (e.g., dig-in), corrosion,
material defect and operating error causing the integrity of a gas pipeline to be
compromised or when repairs to the affected pipeline must be delayed. It usually results
in the utility reducing pressure or shutting down the line. The complete definition is
found in 49 CFR, Parts 191.23 and 191.25. Repairs are often done by utilities before
reaching the requirement for safety-related condition reporting. As a result, California
utilities file a small number of these reports (1 to 5) during the calendar year.
9
7. Drug and Alcohol Testing Program
Utility Drug Testing Programs were required by DOT in 1990. Alcohol testing was
incorporated in 1995. Each utility is now required to have a drug and alcohol testing
program that conforms to the guidelines set forth by DOT in 49 CFR, Parts 40 and 199.
In essence, each utility is required to randomly test utility employees who perform
"emergency response functions" in accordance with DOT's procedures. USRB audits
these drug and alcohol programs, at the headquarters of each utility, to determine
compliance with DOT requirements. USRB audits the procedures, which includes the
collection process and the chain of custody of the sample in the drug testing laboratory.
The audits are supplemented by information gathered in periodic GO 112-E audits of the
operator’s field offices where questions are asked concerning the Drug and Alcohol
Programs.
Propane operators and MHP master-meter operators are exempt from the drug and
alcohol testing programs (49 CFR 199.2).
8. Underground Service Alert (USA)
USA was established to minimize the damage caused to underground facilities by
excavation in California and Nevada. USA is funded by its member utilities (gas,
electric, water, telephone, cable, etc.) that are at risk. Each USA member pays dues
based on either miles of facilities in the ground or population with some weight given to
the importance of the buried facilities (e.g., a fiber optic cable or large high pressure gas
line has more importance than a 2 inch water line). There are two USA call centers in
California (USA North which covers central and northern California and DigAlert which
covers southern California) and each provides a toll-free number for excavators to call
two business days before beginning excavation activities. USA notifies utilities that have
facilities in the area to locate and mark them so the excavator will be aware of their
location prior to digging.
10
Calls made to their respective toll-free numbers are directed to one of two USA call-
center organizations in California. However, since May of 2007 a single national
number, 811, automatically directs callers to the nearest one-call center. Approximately
600,000 calls are made annually to the California’s USA call centers. Excavators are
much less likely to cause pipeline damage when they call before they dig. USRB has
endeavored to promote legislation to increase penalties for not calling USA, especially
for repeat offenders. State Contractor’s License Board may revoke a contractor’s license
if it is determined that the contractor is ignoring the rules. USRB maintains a database to
record excavation damage to pipelines and uses it to monitor the effectiveness of the
program.
The Common Ground Alliance (CGA) is a nationwide member-driven association
dedicated to ensuring public safety, environmental protection, and the integrity of
services by promoting effective damage prevention practices. In recent years, the
association has established itself as the leading organization in an effort to reduce damage
to all underground facilities in North America through shared responsibility among all
members. Members include representatives from both regulatory agencies and industry.
CGA has various regional organizations such as the California Regional Common
Ground Alliance (CARCGA). USRB is an active participant in the CARCGA.
9. Pipeline Replacement Program (PRP)
The PRP is of paramount importance to gas utilities. Its purpose is to replace old gas
pipelines, which are technologically obsolete and prone to leakage or failure, with new
pipelines. Pacific Gas and Electric Company (PG&E) and Southern California Gas
Company (SCG) have implemented programs which evaluate the numerous factors that
must be considered in determining the priority of replacement. In general, the type of
pipeline, age, condition, location, proximity of known faults, population density and leak
history are the major considerations in setting the priority. As a result of the Loma Prieta
earthquake in 1989, seismic effects were added as a major consideration in the formula.
A seismic factor is assigned to each pipeline segment by using four components: (1) the
11
probability of strong ground shaking, (2) the probability of surface faulting, (3) the
susceptibility to soil liquefaction and (4) the susceptibility to slope failure or landslide.
PG&E and SCG presently use all these factors to develop a priority list for pipeline
replacement. Both programs are well designed and appear to be an accurate method for
planning and financing future replacements systematically. Each utility tracks the
progress of its program, detailing what has been accomplished and what remains to be
completed. The priorities may be modified with substantial cause, which provides a
utility with program flexibility. For example, when a utility learns of a planned re-paving
project, it may rearrange priorities so that scheduled pipeline replacement can be
accomplished just before the start of the re-paving.
Cast iron pipeline replacement has always been at or near the top of SCG and PG&E's
priority lists. Southwest Gas Corporation (SWG) and San Diego Gas and Electric
Company (SDG&E) do not have cast iron pipe in their systems. SCG completed
replacement of the last of its existing cast iron pipeline during 2005. PG&E still has
approximately 117 miles of cast iron pipeline (mainly in the San Francisco Bay Area) in
its distribution system as of the end of 2007. PG&E is systematically replacing these
pipelines as well as other high priority pipelines. In identifying high priority pipelines,
PG&E takes into account its age, leak history, cathodic protection measures in place,
seismic susceptibility and structure and population proximity. Beginning in 2007, PG&E
started to focus its pipeline replacement program on copper services. PG&E projects that
it will complete its pipeline replacement program by 2014.
Pre-1931 steel distribution mains and steel transmission lines with joint configurations
and girth welds not meeting current standards are also a high priority on all utility
pipeline replacement programs.
Quantities by type of both transmission and distribution pipelines are given in Tables 2
and 3 in Section IV.
12
Leak surveys and evaluations regarding the cause of recently repaired pipelines are used
to judge the original pipeline replacement priorities. This coupled with unforeseen
events, such as natural disasters, changes in operating conditions, city or county re-
paving programs, load shifts and funding all have an impact on the original set of
priorities. With proper cause, replacement priorities can and should be modified. USRB
monitors these modifications and determines if they are in the best interest of public
safety.
10. Operator Qualification and Pipeline Integrity Management
In 2005, PHMSA changed its operator qualification regulations to conform to section 49
USC 60131 enacted by the Pipeline Safety Improvement Act of 2002. Among the
changes was the required inclusion of training “as appropriate.” Persons performing any
task on a natural gas facility must be qualified to perform the particular task. DOT
clearly recognizes and emphasizes operator qualification as an important component of
pipeline safety.
The Pipeline Safety Improvement Act also directed PHMSA to establish a Pipeline
Integrity Management Program (IMP). In response PHMSA issued Subpart “O”
containing sections 192.903 to 192.949 on May 26, 2004. This Subpart establishes a
risk-based assessment program that requires operators of gas transmission pipelines to (1)
identify all the segments located in “high consequence areas” (HCAs) - areas adjacent to
significant population or frequently used areas, such as parks; (2) develop an IMP to
reduce the risks to the public in such areas; (3) undertake baseline integrity assessments
(inspections) at all segments located in the HCAs within 10 years; (4) develop a process
for repairing any anomalies found in these inspections; and (5) reassess these segments
every seven years thereafter to verify continued pipeline integrity. One-half of the
baseline assessments must be done by December 2007 and the remainder by December
2012. The risks to be assessed include corrosion, welding defects and failures, third-
party damage, land movement, and improper operation. As of the end of 2007, major gas
operators reported that there are approximately 2,380 miles of HCA pipeline in California
with approximately 21 % of the HCAs inspected. USRB believes that all CPUC
13
jurisdictional gas operators met the December 17, 2007 requirement to assess at least
50% of their highest risk HCA pipeline segments.
11. Pipeline Inspection, Protection, Enforcement and Safety Act
On December 29, 2006 the President signed into law new legislation entitled the Pipeline
Inspection Protection, Enforcement and Safety Act (PIPES Act). Key elements of the
PIPES Act are:
• Improves state programs to reduce excavation damage to pipelines and
strengthens federal enforcement of damage prevention laws.
• Requires that a Distribution Integrity Management Program be implemented
• Requires excess flow valves to be installed on all new residential natural gas
service lines, where feasible, beginning June 1, 2008.
• Adopts new regulations requiring operators of gas pipeline systems to evaluate
and reduce the risks associated with human factors such as fatigue.
• Creates an emergency waiver process
• Implements a pipeline corrosion research program
12. Meter Protection Program
In its 1990 General Rate Case, PG&E introduced a meter protection program because a
statistical analysis conducted in cooperation with the CPUC indicated a major cause of
gas incidents was vehicles hitting meters and rupturing gas pipelines. The CPUC
approved $5 million for the first year of a 27-year program and required PG&E to file
annual reports on the program’s progress similar to the reports it files on its Gas Pipeline
Replacement Program. Meter readers identify meters that they feel are vulnerable to
being struck by a vehicle. An expert evaluates these meters and many are slated to be
protected. The PG&E program is scheduled to run through 2016. Other gas utilities are
required to protect their gas meters from vehicular damage by CFR 49 §192.353 without
specific CPUC-approved programs for the purpose.
14
In 2007, PG&E inspected a total of 512 meter locations and performed 907 corrective
actions to protect the meters.
13. Granting Of Waivers
The process of granting a waiver is initiated by a request from a regulated utility seeking
permission to deviate from existing regulations. These requests usually involve new
products or gas safety technology. USRB evaluates each request for a waiver to
determine if it will provide an acceptable level of safety. If USRB supports a request for
a waiver, it will prepare a resolution for CPUC approval to granting the waiver
contingent upon DOT (Office of Pipeline Safety) approval. If the waiver is granted, the
utility may proceed with the project for which the waiver was granted. It cannot use this
technology elsewhere until DOT incorporates the new technology into the regulations or
the utility requests and is granted a new waiver to use the technology in another project.
A good example of how a request for a waiver could be incorporated into the regulations
is SCG’s request for a waiver to install polyethylene pipe larger in diameter than allowed
by regulations. SCG was convinced that the larger pipe was safe and economical to use
in its gas system. Eventually the regulations were changed to allow the larger diameter
pipe to be installed.
14. Above Ground Pipe Inspections
Inspections of above ground pipeline were initiated in 1990 after significant corrosion
was observed on a major transmission pipeline. Inspections revealed differences in the
surface conditions of exposed piping in different districts within the same utility. In
some districts above ground piping was in excellent condition while in an adjacent
district, there were frequent instances of surface rust and pitting. All utilities are required
to keep inspection records for above ground facilities including frequency of inspection
and findings. These records are reviewed during the course of normal GO 112-E
inspections.
15
15. Other Programs
USRB is currently looking at new technology for ways to address needed improvements
in gas safety. One need is to improve the existing method for controlling the flow gas
during and immediately after a seismic occurrence. Several types of seismic shutoff
valves have been designed. These valves are triggered by the motion or vibration of an
earthquake to shut off the gas supply to a building. The City of Los Angeles adopted an
ordinance to mandate installation of these valves on all new construction. SCG
conducted a pilot program to install these devices but discontinued the program due to
concerns about false closures and liability. Numerous valves have been installed in
southern California at customer expense by plumbing contractors downstream of the
customer meter. It is expected that most of the existing seismic shut-off valves will
initially experience some problems.
Seismic shutoff valves can be triggered by vibrations other than from an earthquake, such
as vibrations caused by a large passing truck. Also, all the valves in an area will trip
during an earthquake even though most of the protected houses do not have gas leaks.
Relighting pilots in an area where a majority of houses are protected by seismic shutoff
valves can be time consuming and diverts labor from other recovery tasks. Also,
homeowners may carelessly attempt to relight their own pilots creating
hazardoussituations.
Excess flow valves shut off gas when they sense a sudden increase in the rate of flow of
gas such as from a pipe break. These valves provide some protection from earthquake
damage without the nuisance trip problem. This type of valve has gained greater
acceptance among regulatory agencies and utilities. They would not be effective against
small leaks caused by movement of houses in an earthquake though.
Other firms are working on a product that would sense the presence of gas in the air. The
sensor would detect the amount of methane (CH4) in the environment and possibly
carbon monoxide (CO), and at preset levels would shut off the gas supply to the building.
The device would also sound an alarm much like a smoke detector notifying the
16
occupants with two alarms: first, that there is a problem and the gas is about to be shut
off and second, when the gas is automatically shut off.
USRB is also looking at better ways to measure the condition of pipelines.
Manufacturers continue to make improvements to magnetic flux leakage detecting
devices, often referred to in the industry as “smart pigs,” that are inserted into a gas
pipeline, travel through it and locate any areas of corrosion, cracks, or signs of third
party-damage. These devices allow for high quality inspections of pipelines without
unduly curtailing their flow. Other devices such as pipe liners capable of being inserted
into existing pipelines may greatly reduce the cost of pipeline replacement especially in
highly populated areas. System Control and Data Acquisition (SCADA) systems are
being used to remotely monitor critical pipeline facilities and in some cases, work as an
early warning system to alert the utility to a potential problem such as over
pressurization. Another form of pipeline corrosion direct assessment is guided wave
ultrasonic testing. Guided wave technology has been found to be particularly
advantageous for assessing pipeline for which a smart pig cannot be used. Programs
continue to be enacted as a result of information gathered following a natural disaster
(e.g., the water heater strapping program resulted from investigations of the causes of
natural gas fires following an earthquake).
16. Other Duties Required by the Pipeline Safety Act
USRB is required to monitor each of the regulated utility’s major construction projects,
pipeline pressure uprates, and hydro tests. In addition, USRB reviews the type of
project (new or replacement), the location of the project, and the pipeline material being
used. It also performs random inspections of these activities. These inspections are
usually conducted when time permits or a significant job warrants an inspection.
17
17. DOT Annual Audit
USRB is audited annually by the DOT to verify its ability to perform as an agent for the
federal government. In 2007, USRB’s gas program was scored 100% by the DOT. The
level of federal funding to USRB for natural gas and propane system inspections carried-
out on behalf of the DOT is based upon the results of this audit. The audit consists of
reviewing USRB's records of the previous year. Records regarding incident reports,
inspections, citations for noncompliance and knowledge of the federal regulations are
reviewed. The federal inspector also verifies that each state inspector spends a minimum
number of days in the field. The DOT requires USRB to account for its actions and to
have its inspectors fully trained by attending all the courses provided by the Office of
Training and Qualifications.
18
SECTION II: ELECTRIC SAFETY INSPECTIONS, REPORTS, AND PROGRAMS
1. Electric Safety and Inspection Program In 2006, USRB revised the process by which it conducts electric safety audits. In the
past, USRB inspectors would conduct inspections of the electric utilities’ overhead and
underground facilities to ensure compliance with GO 95 and 128, respectively. USRB
now focuses on the compliance aspects of GO 165 when conducting its electric safety
audits.
GO 165, “Inspection Cycles for Electric Distribution Facilities”, became effective March
31, 1997. Its purpose is to establish minimum inspection cycle requirements for electric
distribution facilities, condition ratings, scheduling and performance of corrective action,
record keeping, and reporting in order to ensure safe and high quality electrical service.
All utilities subject to GO 165 are required to submit an annual report describing the
status of their inspections and repairs, and future schedules for inspections.
Under the provisions of GO 165, the electric companies must patrol and inspect their
electric facilities on a routine basis. During these routine patrols and inspections, the
electric companies must identify and document all GO 95 and 128 violations discovered
and take corrective action in accordance with their maintenance programs.
The requirements of GOs 95 and 128 are essential elements of the GO 165 patrol and
inspection process. GO 95, “Rules for Overhead Electric Line Construction”, became
effective July 1, 1942. The rules formulate uniform requirements for overhead electrical
line construction. GO 128, “Rules for Construction of Underground Electric Supply and
Communications Systems”, became effective December 12, 1967. These rules formulate
uniform requirements for underground electrical supply and communication systems.
19
Both General Orders are frequently revised to keep up with changes in electric utility
technology and practice. The latest edition of GO 95 was issued in August 2007, and GO
128 in January 2006. The application of these requirements provides adequate service
and secures safety to all persons engaged in the construction, maintenance, operation or
use of overhead and underground electrical facilities (including telephone and cable) and
to the general public.
During an electric audit, USRB inspectors will review utility records to ensure
compliance with GO 165. The inspectors will determine from the records if the utility
conducted its patrols and detailed inspections as required and if GO 95 and 128 violations
were properly documented and corrective action taken in accordance with the utility’s
maintenance program.
Once the review of records is completed, USRB inspectors will perform a quality
assurance review in the field on a representative sample of overhead and underground
facilities that were recently inspected by the utility. USRB inspectors will determine
from this review if the utility properly identified, documented, and repaired GO 95 and
128 violations in accordance with its maintenance program. In addition, USRB
inspectors will inspect newly constructed or reconstructed electric facilities to ensure
compliance with GOs 95 and 128.
USRB inspectors will document all GO 95, 128, and 165 compliance issues observed
during the electric audits. Normally, within 30 days after each audit, a report containing
USRB’s findings will be sent to the utility. If violations are noted in the report, the utility
is required to respond with a plan of action to correct the violations.
2. Incident Reporting and Investigation In addition to enforcing the above general orders, USRB staff conducts investigations of
reportable incidents from the utility companies. Section 315 of the PU Code provides
that the CPUC shall investigate the cause of accidents occurring upon the property of any
utility, or arising from or relating to the maintenance or operation of the utility’s system.
20
Reportable electric incidents are defined in Appendix B to CPUC Decision No.
98-07-097 as those which: (a) result in fatality or personal injury rising to the level of in-
patient hospitalization and attributable or allegedly attributable to utility owned facilities,
(b) involve property damage that exceeds $20,000, (c) are the subject of significant
public attention or media coverage and are attributable or allegedly attributable to utility
facilities.
USRB staff also responds to safety related customer complaints pertaining to GOs 95,
128, and 165. This may range from responding to a telephone inquiry or correspondence
to conducting a formal investigation.
3. Heat Storm
Much of California experienced a heat storm for two weeks during July 2006. The
California Energy Commission defines a heat storm as a weather condition in which
temperatures exceed 100 degrees Fahrenheit over a large area for three consecutive days
or more.
In 2006, USRB initiated a review of the outages that were caused by the failures of
distribution transformers during the heat storm. The focus of the review was to
determine if there were actions that could have been taken by utilities prior to the heat
storm to reduce the number of outages. Furthermore, USRB is exploring alternatives
that can be implemented in the future to help minimize outages in the event of another
heat storm. In 2007, USRB expanded the investigation to examine the effectiveness of
transformer replacement programs and specifically the cost impact. USRB expects to
publish a report on its findings in 2008.
4. Substation Inspection Program
On December 20, 2003, a fire occurred at the PG&E Mission Substation in San Francisco
that caused an electric outage in the San Francisco area. On February 16, 2006, the
CPUC issued D.06-02-003 based on its investigation into the causes of the fire and
21
subsequent outage. The decision approved a settlement agreement among CPSD, the
City and County of San Francisco and PG&E. As part of the settlement, PG&E
contributed $500,000 to assist CPSD in establishing a substation inspection program.
In 2007, the Utilities Safety and Reliability Branch (USRB) met with the Investor Owned
Utilities in California to better understand Substation Operation and Maintenance
Programs, and witnessed CASIO audits of SDG&E, and PG&E substations. USRB staff
attended training in substation equipment, and high voltage electrical safety. In October
2007, USRB drafted a proposed General Order which will regulate the Operation and
Maintenance of utility substations.
5. GO 95 Antenna Rule On February 24, 2005, due to an increase in the number of antennas on utility poles, the
CPUC issued an Order Instituting Rulemaking (OIR) that proposed revisions to GO 95
that would establish uniform construction standards for attaching wireless antennas to
jointly used utility poles and towers. Over the course of the OIR, USRB participated in
evidentiary hearings and workshops on matters pertaining to the proposed rule. A final
settlement was achieved and adopted in D.07-02-030 on February 15, 2007.
D.07-02-030 ordered that new rules (Rule 20 and 94) and Appendix H be added to GO 95
to address the issue of antennas on jointly used utility poles.
In July 2007, the California Cable and Television Association, acting on behalf of the GO
95/ 128 Rules Committee, filed a petition (P.07-07-020) to modify GO 95, Rule 94,
specifically those portions that do not allow antennas to be located above supply lines. In
December 2007 the Commission opened a rule making proceeding (R.07-12-001), to
address the petition.
6. Fire Storm
In October 2007, several fires erupted in Southern California. The fires caused fatalities
and injuries, power outages, evacuations, and millions of dollars in property damage.
22
USRB staff investigated the fires to determine if they were caused by electric facilities
owned and operated by the electric utilities providing service to the affected areas. The
locations of the fires USRB staff investigated are indicated in Figure 1, Map Fire, and the
results of the fires are contained in Table 1, Fire Summary.
Figure 1, Fire Map
Name Fatalities Injuries Acres Burned
Destroyed / Damaged
1 Castaic Fire 0 0 58,491 1 home 9 outbuildings
2 Malibu Fire 0 0 3,836 33 structures 3 Cajon Fire 0 0 250 4 Grass Valley Fire 0 1 1,247 199 homes
2 outbuildings 5 Rice Canyon Fire 0 0 9,472 206 homes
40 outbuildings 2 commercial
6 7
*Guejito Fire Witch Fire
2 40 197,990 1,218 homes 534 outbuildings
23
239 vehicles Table 1, Fire Summary
*The Guejito and Witch Fires merged into one fire. The fires occurred in the service territories of SCE (Castaic, Malibu, Cajon, and Grass
Valley Fires) and SDG&E (Rice Canyon, Guejito, and Witch Fires). The fires occurred
during the time when Santa Ana winds were present, which are common in Southern
California in the summer and early fall. USRB staff is investigating the fires to
determine if the wind conditions contributed to the fires by damaging the electric power
lines. USRB plans to issue its reports and findings in 2008. 7. Communication Infrastructure Providers (CIP)
In recent years, USRB has focused its overhead inspection program on utilities providing
power. GOs 95 and 128 apply also to communication facilities but GO 165 inspection
cycles do not. Having changed its procedure for safety enforcement on supply utilities,
USRB has been developing a new inspection program for communication utilities. It is
often the case that CIPs share underground and overhead space with supply utilities and
generally abide by the same rules. In 2007, USRB moved forward with its plans for
specific telecommunications inspections by meeting with cable television and telephone
providers to develop a new CIP inspection program. In 2008, USRB will conduct a few
CIP inspections with the objective of refining and expanding the program.
24
SECTION III: UTILITY COMPANIES
The CPUC has authority under the PU Code to enforce the requirements of GO 112-E on
investor owned gas utilities. The CPUC also has authority under the PU Code to adopt
and enforce the requirements of GOs 95, 128, and 165 requirements on all electric and
communication utilities. There are a number of investor-owned electric, gas and
communication utility companies providing service in California as well as utilities
operated by municipalities and cooperatives.
1. Major Natural Gas and Electric Utilities
2. Pacific Gas and Electric Company (PG&E) Pacific Gas and Electric provides gas service to about 4.1 million
customers and electric service to about 5.2 million customers. Its
service area covers 70,000 square miles.
25
2. Other Natural Gas Companies
SMALL COMPANIES
• ALPINE NATURAL GAS
3. San Diego Gas and Electric Company (SDG&E) San Diego Gas and Electric provides natural gas service to approximately
825,000 customers and electric service to 1.3 million customers in San
Diego and Orange County.
5. Southern California Edison Company (SCE) SCE provides electric service to 4.8 million customers and operates a
propane gas system on Catalina Island that serves approximately 1,300
customers. It also transports gas to one of its power plants. Its service
area covers 50,000 square miles.
26
• WEST COAST GAS
MUNICIPALITIES
• LONG BEACH
• PALO ALTO
• SUSANVILLE
• COALINGA
NATURAL GAS STORAGE FACILITIES
• LODI UNDERGROUND STORAGE
• WILD GOOSE STORAGE
3. Other Electric Service Companies
INVESTOR OWNED COMPANIES
• BEAR VALLEY ELECTRIC
• MOUNTAIN UTILITIES
• SIERRA PACIFIC POWER COMPANY
• PACIFICORP.
ELECTRIC COOPERATIVES
• SURPRISE VALLEY ELECTRIFICATION CORP.
• PLUMAS-SIERRA RURAL CO-OP.
• ANZA ELECTRIC COOPERATIVE
• VALLEY ELECTRIC ASSOCIATION, INC.
MUNICIPALITIES
27
ALAMEDA ANAHEIM
AZUSA BANNING
BIGGS BURBANK
COLTON GLENDALE
GRIDLEY HEALDSBURG
HERCULES IMPERIAL IRRIGATION DISTRICT
ISLAND ENERGY LASSEN MUNICIPAL UTILITY DIST.
LODI LOMPOC
LOS ANGELES DWP MODESTO IRRIGATION DIST
NEEDLES NORTHERN CAL. POWER AGENCY
OROVILLE-WYANDOTTE IRRIGATION DIST. PALO ALTO
PASADENA REDDING
RIVERSIDE ROSEVILLE
SACRAMENTO MUNICIPAL UTILITY DIST. SILICON VALLEY POWER
SHASTA LAKE SOUTHERN CAL. PUBLIC POWER AUTH.
MORENO VALLEY TRINITY COUNTY
TRUCKEE DONNER PUBLIC UTILITY DIST TURLOCK IRRIGATION DIST
UKIAH VERNON
VICTORVILLE
28
SECTION IV: GAS STATISTICS
This section describes the California gas system, summarizes USRB inspection results for
2007, and discusses gas incidents and customer complaints.
1. Size and Character of the California Gas System
The California gas system (natural gas and propane) serves approximately 11 million gas
customers with approximately 100,000 miles of gas mains. Table 2 and Figure 2
illustrate the miles and types of distribution pipeline as reported by the operators to the
DOT. Table 3 and Figure 3 indicate the miles and types of transmission pipeline by
utility. Table 4 and Figure 4 show the number and types of services of each utility on
their system during 2007. Table 5 lists the cause of repaired leaks determined by each
utility on their systems during 2007. Figure 5 illustrates an overview of the causes of
repaired leaks in 2007.
PG&E and SCG are two of the largest utilities in the United States and serve most of the
northern and southern portions of California, respectively. SDG&E is significantly
smaller and serves the greater San Diego area. SWG is smaller still and serves Lake
Tahoe and the high desert near Victorville. SCE also operates a small propane gas
system on Catalina Island. SCE upgraded the system in 2005 with the addition of a
mixed gas (propane/air) transportation tank and the deletion of a storage tank. Alpine
Natural Gas, a small company, takes gas from a PG&E transmission line to serve
customers who were previously served by propane. Finally, MHPs and other multi-
family residential facilities may be served by a natural gas master-metered or propane
system.
California also has independent firms that have developed underground storage to serve
California utilities such as Wild Goose Storage and Lodi Underground Storage. Despite
29
their size, these systems fall under CPUC jurisdiction and are required to follow state and
federal regulations.
Steel Pipe
Unprotected Protected Company Bare Steel Coated
Steel Bare Steel
Coated Steel
Plastic Cast Iron Total
PG&E 213 0 0 20,880 20,528 182 41,803 SCG 3,381 5,600 149 16,713 21,723 0 47,566 SDG&E 0 0 0 3,731 4,607 0 8,338 SWG 0 1 0 613 2,419 0 3,033 SCE 0 0 0 9 0 0 9 Total 3,594 5,601 149 41,946 49,277 182 100,749
Table 2. Miles of Distribution Pipeline in 2007, by Utility
Distribution Pipeline In Use 2007
Coated Steel41.63%
Plastic48.91%
Protected Bare Steel0.15%
Coated Steel5.56%
Bare Steel3.57%Cast Iron
0.18%
Figure 2. Distribution Pipeline in 2007, by Type
30
Unprotected Protected Company Bare
Steel Coated Steel
Bare Steel
Coated Steel
Total
PG&E 0 0 8,727 5,702 14,429 SCG 7 2 7 3,945 3,961 SDG&E 0 0 0 243 243 SWG 0 0 0 20 20 SCE 0 0 0 0 0 Total 7 2 8,734 9,910 18,653
Table 3. Miles of Transmission Pipeline in 2007, by Type and Utility
Transmission Pipeline In Use 2007
PG&E77.4%
SWG0.1% SDG&E
1.3%
SCG21.2%
Figure 3. Transmission Pipeline in 2007, by Utility
31
Steel Pipe Unprotected Protected Company
Bare Coated Bare Coated Plastic Copper Total
PG&E 18,310 0 0 1,208,732 1,953,342 77,080 3,257,464 SCG 172 1,025,548 21 765,114 2,482,058 7,662 4,280,575 SDG&E 0 0 0 263,736 322,175 0 585,911 SWG 0 0 0 11,987 153,276 0 165,263 SCE 0 0 0 816 164 0 980 Total 18,482 1,025,548 21 2,250,385 4,911,015 84,742 8,290,193
Table 4. Number of Services in 2007, by Utility
2007 Gas Distribution Services
SCG51.62%
PG&E39.35%
SWG2.01%
SCE0.01%
SDG&E7.01%
Figure 4. Gas Services in 2007, by Utility
32
Company Corrosion Natural
Forces Excavation Outside Force
Material or Welds Equipment Operations Other Total
PG&E 1,482 119 3,275 118 1,966 6 0 900 7,866
SCG 4,688 88 5,323 1,571 216 8 0 1,268 13,162
SDG&E 533 19 252 81 107 64 0 91 1,147
SWG 7 7 418 3 72 13 24 6 550
SCE 2 0 1 1 0 0 0 0 4
Total 6,712 233 9,269 1,774 2,361 91 24 2,265 22,729
Table 5. Leaks Repaired in 2007, by Utility
Repaired Gas Leaks in 2007
6,712
233
9,269
1,774
2,361
91
24
2,265
0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000
Corrosion
Natural Forces
Excavation
Outside Force
Material or Welds
Equipment
Operations
Other
Figure 5. Leaks Repaired in 2007, by Type
2. USRB Inspection Data During 2004 and 2005, USRB was divided into two units. Each unit was assigned
specific counties in which to conduct GO 112-E inspections in California. The counties
inspected by each unit were:
Northern Unit: Alameda, Alpine, Amador, Butte, Calaveras, Colusa, Contra Costa, Del
Norte, El Dorado, Fresno, Glenn, Humboldt, Inyo, Kern, Kings, Lake, Lassen, Madera,
33
Marin, Mariposa, Mendocino, Merced, Modoc, Mono, Monterey, Napa, Nevada, Placer,
Plumas, Sacramento, San Benito, San Francisco, San Luis Obispo, San Joaquin, San
Mateo, Santa Barbara, Santa Clara, Santa Cruz, Shasta, Sierra, Siskiyou, Solano,
Sonoma, Stanislaus, Sutter, Tehama, Trinity, Tuolumne, Tulare, Yolo, and Yuba.
Southern Unit: Imperial, Los Angeles, Orange, Riverside, San Bernardino, San Diego
and Ventura.
Section I, Subsection 2, contains a description of a typical GO 112-E inspection.
Each inspection of a gas utility is documented and maintained in a file for a period of at
least 3 years. Each unit of a gas utility is inspected every two or three years. Gas units
may be inspected more frequently if conditions are unsatisfactory or not in compliance
with GO 112-E.
MHP gas systems are to be inspected once every five years. Propane systems are to be
inspected once every two, three or five years, depending upon the size of the propane
system. MHP and propane systems may be inspected more frequently if the systems are
not in compliance with GO 112-E. USRB also reviews Annual Reports submitted by
MHP and propane systems operators to determine if more frequent inspections are
warranted.
The DOT provides funding for the CPUC to inspect intrastate gas pipelines for
conformance to federal regulations in addition to state regulations. The DOT provides
significant funding to the CPUC to perform these inspections. The level of funding is
determined by funds allotted to DOT by Congress and an annual audit of USRB records
(see Section I, subsection 16).
An overall summary of USRB inspections of the gas utilities and MHP and propane
systems is given in Table 6 below. Table 7 presents GO 112-E inspections by utility.
GO 112-E MHP Propane Total
34
Inspections 31 716 204 951
Infractions 59 2,967 680 3,706
Table 6. Summary of GO 112-E Inspections in 2007
Utility 2007 PG&E 10 SCG 9 SDG&E 4 Sempra (Combined SCG/SDG&E) 1 SWG 5 West Coast Gas Storage 2 TOTAL 31
Table 7. Gas Utility Inspections in 2007
3. Gas Incidents
USRB staff receives and investigates reports of gas and propane incidents from regulated
utility companies and MHP and propane system operators. GO 112-E defines reportable
incidents as those which involve a release of gas and: (a) result in a fatality or personal
injury rising to the level of in-patient hospitalization, (b) cause over $50,000 in damage
including the loss of gas, or (c) become the subject of significant public attention or
media coverage.
The gas utility companies and MHP and propane operators are required to provide notice
of a reportable to designated USRB staff within two hours during working hours or four
hours during non-working hours. The notice must identify the time and date of the
incident, the location of the incident, identification of casualties and property damage,
and the name and telephone number of a utility contact person.
USRB maintains an incident database, which tracks incidents by cause. These causes are
divided into construction/material defects, corrosion, excavation, vehicle, unknown or
other. Table 8 summarizes incidents by cause for 2007. Figure 6 shows reportable
35
incidents by cause for 2007. In 2007, 55% of the reportable gas incidents were caused by
excavation.
Cause Total
Corrosion 1 Excavation 49 Vehicle 13 Fire 11 Other 12 Unknown 3 Total 89
Table 8. Reportable Incidents in 2007, by Cause
Reportable Gas Incidents By Cause 2007
1
49
13
11
12
3
0 10 20 30 40 50 60
Corrosion
Excavation
Vehicle
Fire
Other
Unknown
Figure 6. Comparison of Reportable Incidents in 2007
36
SECTION V: ELECTRIC STATISTICS
This section contains information and statistical data on the various electric related
activities conducted by USRB during 2007.
USRB is responsible for enforcing the provisions of GOs 95, 128, and 165. USRB
conducts periodic inspections of both overhead and underground electric power and
communication lines throughout the state. This involves both document audits and field
inspections. USRB maintains records of the inspections and monitors the utilities to
ensure violations are corrected.
USRB also investigates accidents involving overhead and underground electric and
communication lines as mandated by PU Code Section 315 to determine if the utilities
are at fault for non-compliances with the GOs.
USRB is divided into a Northern Unit and a Southern Unit for electric inspections as
follows:
Northern Unit: Alameda, Alpine, Amador, Butte, Calaveras, Colusa, Contra Costa, Del
Norte, El Dorado, Fresno, Glenn, Humboldt, Inyo, Kern, Kings, Lake, Lassen, Madera,
Marin, Mariposa, Mendocino, Merced, Modoc, Mono, Monterey, Napa, Nevada, Placer,
Plumas, Sacramento, San Benito, San Francisco, San Luis Obispo, San Joaquin, San
Mateo, Santa Barbara, Santa Clara, Santa Cruz, Shasta, Sierra, Siskiyou, Solano,
Sonoma, Stanislaus, Sutter, Tehama, Trinity, Tuolumne, Tulare, Yolo, and Yuba.
Southern Unit: Imperial, Los Angeles, Orange, Riverside, San Bernardino, San Diego, and Ventura.
37
California has one of the largest electric and communications systems in the United
States. Major utility data is presented in Table 9 and Figure 7 for overhead equipment.
Utility data for underground facilities is presented in Table 10 and Figure 8. Customer
data is provided in Table 11 and Figure 9. USRB inspection results are provided in Table
12.
1. Major Electric Utility Data (Overhead)
Utility Company Transmission
Lines (miles) Distribution Lines
(miles) Total Overhead
Lines (miles) Number of
Poles PG&E 18,515 113,525 132,040 2,305,000 SCE 11,675 59,870 71,545 1,486,399 SDG&E 1,741 6,713 8,454 216,881 PacificCorp. 741 2,293 3,034 67,303 Sierra Pacific Power 1041 2,812 3,853 22,653 Total 33,713 185,213 218,926 4,098,236
Table 9. Summary of Utility Overhead Facilities in 2007, by Utility
2007 Overhead Transmission And Distribution
18,515 11,675 1,741 7411,041
113,525
59,870
6,7132,812
2,2930
20,000
40,000
60,000
80,000
100,000
120,000
PG&E SCE SDG&E PacificCorp. Sierra PacificPower
Utility
Mile
s
Transmission Distribution
Figure 7. Overhead Distribution and Transmission in 2007, by Utility
38
2. Electric Utility Data (Underground)
Utility Company Transmission Lines (miles)
Distribution Lines (miles)
Total Underground Lines (miles)
Surface Mounted
Structures Underground
Structures
PG&E 165 27,159 27,324 135,928 203,893 SCE 292 39,843 40,135 123,864 334,442
SDG&E 91 9,822 9,913 109,928 43,936 PacificCorp. 0 581 581 5,892 236
Sierra Pacific Power 0 779 779 2,309 1,762 Total 548 78,184 78,732 377,921 584,269
Table 10. Underground Electric Facilities in 2007, by Utility
Underground Transmission And Distribution
165292 91 0 0
27,159
39,843
9,822
581779
0
5000
10000
15000
20000
25000
30000
35000
40000
45000
PG&E SCE SDG&E PacificCorp. Sierra PacificPower
Utility
Mile
s
Transmission Distribution
Figure 8. Underground Transmission and Distribution in 2007, by Utility
3. Electric Utility Customer Data
39
Utility Company Number of CustomersPG&E 5,209,310 SCE 4,851,010
SDG&E 1,364,905 PacificCorp. 44,827
Sierra Pacific Power 46,030 Total 11,516,082
Table 11. Customer Data for Major Electric Utilities in 2007
Percentage of Total Customers for Major Privately Owned Electic Utilities in 2007
SDG&E12%
SCE42%
PG&E46%
Figure 9. Comparison of Total Electric Customers in 2007, by Utility
[Sierra Pacific Power and PacifiCorp are <1% of total]
40
4. USRB Electric Inspection Data
Infractions Utility Inspections
GO 165 GO 95 (overhead)
GO 128 (underground)
Pacific Gas and Electric 7 10 25 7 Southern California Edison 6 1 239 113 San Diego Gas and Electric 2 4 10 2 Sierra Pacific Power 0 0 0 0 Municipalities / Others 13 6 195 85 Total 28 21 469 207
Table 12. USRB Electric Inspections and Infractions in 2007, by Utility
5. Electric Incidents
USRB staff receives and investigates reportable electric incidents from regulated utility
companies. The electric utility companies are required to provide notice to the
designated USRB staff within two hours of an incident. The notice shall identify the
time and date of the incident, the location of the incident, identification of casualties and
property damage, and the name and telephone number of a utility contact person.
USRB staff may investigate incidents at any time. An on-site inspection is performed as
soon after notification as possible if a fatality or serious injury has occurred. If it is
determined that a GO violation was involved, staff prepares a report and recommends
appropriate action against the utility.
USRB maintains a database to record and monitor incidents. If USRB recognizes an
increasing trend in one type of incident reported, USRB staff will investigate and work
with the utilities to correct the problem. In the past the CPUC has initiated Orders
Instituting Investigation based upon the results of USRB’s investigations.
There were 135 electric incidents reported in 2007. Of these, 96 incidents involved
overhead equipment and 39 incidents involved underground equipment.
41
a. Overhead Equipment
Table 13 and Figure 10 represent a summary of the incidents that occurred in 2007.
Vehicles caused the most reportable overhead incidents.
Cause Count Fatalities Injuries Aircraft 3 1 0
Animal 3 0 0
Boom 1 0 0
Crane 4 0 1
Falling Branch 4 1 0
Falling Tree 7 0 0
Fire 1 0 1
Insulator Failure 1 1 0
Line Failure 8 0 0
Metal Object 5 0 4
Natural Cause 4 0 1
Other 9 2 1
Rain Gutter 2 0 0
Switch Malfunction 1 0 0
Transformer Malfunction 4 0 0
Tree Trimmer 3 0 0
Tree/Line Contact 2 0 0
Unknown 9 0 0
Vandalism 5 2 1
Vehicle 11 4 0
Working Overhead 9 2 6
Total 96 13 15
Table 13. Reportable Electric Overhead Incidents with Injuries and Fatalities in 2007
42
Cause Of Overhead Electric Incidents in 2007
3
3
1
4
4
7
1
1
8
5
4
9
2
1
4
3
2
9
5
11
9
0 1 2 3 4 5 6 7 8 9 10 11 12
Aircraft
Animal
Boom
Crane
Falling Branch
Falling Tree
Fire
Insulator Failure
Line Failure
Metal Object
Natural Cause
Other
Rain Gutter
Switch Malfunction
Transformer Malfunction
Tree Trimmer
Tree/Line Contact
Unknown
Vandalism
Vehicle
Working Overhead
Cau
se
Incidents
Figure 10. Graph of Reportable Electric Overhead Incidents in 2007
43
b. Underground Equipment Table 14 and Figure 11 summarize the leading causes of incidents in 2007 related to
underground equipment. The leading cause of accidents involving underground
equipment in 2007 was excavation.
Cause Count Fatalities Injuries
Excavation 13 0 2 Switch Malfunction 2 0 0 Transformer Malfunction 2 0 0 Underground Cable Failure 11 0 0 Underground Splice Failure 5 0 0 Underground Transformer Failure 2 0 0 Unknown 1 0 0 Working Underground 3 0 3 Total 39 0 5
Table 14. Reportable Electric Underground Incidents with Injuries and Fatalities in 2007
Cause Of Underground Electric Incidents (2007)
13
2
2
11
5
2
1
3
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14
Excavation
Sw itch Malfunction
Transformer Malfunction
Underground Cable Failure
Underground Splice Failure
Underground Tranformer Failure
Unknow n
Working Underground
Cau
se
Incidents
Figure 11. Graph of Reportable Electric Underground Incidents in 2007, by Cause
44
SECTION VI: PUBLIC COMPLAINTS AND INQUIRIES
USRB responsibilities include recording, analyzing, and resolving complaints and
inquiries received from the general public for those areas under USRB jurisdiction.
Table 14 provides a summary of inquiries and complaints to USRB in 2007. Figure 12
below provides a comparison of the relative numbers of types of complaints or inquiries.
Electric complaints and inquiries generally involve problems with pole location or
condition, e.g., leaning, height of service drops, height of power lines, proximity of trees
to power lines. Gas complaints and inquiries tend to involve customers smelling gas and
not receiving a fast response from a utility. Telecommunication complaints and inquiries
usually involve service failures or old and abandoned lines. The vast majority of MHP
and propane complaints and inquiries are requests for information regarding annual
reporting requirements, clarification about operator qualifications, and operation and
maintenance plans. Miscellaneous complaints and inquiries involve customers who
called USRB by mistake and needed another branch of the CPUC, or who needed to talk
to another state or local agency, such as the California Department of Forestry and Fire
Protection, or a county planning department, etc. In all cases USRB staff assisted the
callers by providing the proper information.
Recommended